CN106948812B - Method and device for determining permeability lower limit value of hypertonic zone - Google Patents
Method and device for determining permeability lower limit value of hypertonic zone Download PDFInfo
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Abstract
The invention provides a method and a device for determining a permeability lower limit value of a hypertonic zone, wherein the method comprises the following steps: determining the permeability of each stratum of the reservoir to be detected under each plunging coefficient according to the stratum parameters of the reservoir to be detected; establishing an oil reservoir model of the reservoir to be tested for each plunging coefficient and simulating oil extraction to obtain the oil reservoir extraction degree corresponding to each oil reservoir model; based on the change relation of the oil reservoir extraction degree along with the plunging coefficient, selecting the plunging coefficient corresponding to the inflection point in the change relation as the reservoir plunging coefficient of the reservoir to be detected; and finally, calculating to obtain the permeability lower limit value of the high permeability zone in the reservoir to be detected. In the embodiment of the invention, under the condition of obtaining the reservoir plunging coefficient of the reservoir to be detected, the lower limit value of the permeability of the high permeability zone in the reservoir to be detected is calculated by combining the average permeability, so that the aim of quantitatively determining the range of the high permeability zone of the reservoir to be detected is fulfilled, and the exploitation efficiency of oil gas can be effectively improved by guiding oil gas exploration through the determined accurate lower limit value of the permeability.
Description
Technical Field
The invention relates to the technical field of petroleum exploration, in particular to a method and a device for determining a permeability lower limit value of a high permeability zone.
Background
Due to different sedimentary diagenesis conditions of oil reservoir reservoirs, physical properties (such as porosity, permeability and the like) of different parts in a thick oil layer have certain difference. The larger the difference is, the more easily the oil-water reservoir is caused to have the phenomenon that the displacement front of the oil-water reservoir penetrates into the displaced phase in a finger-shaped manner in the displacement process when the waterflood is developed, and correspondingly, the larger the porosity and the permeability are. The reservoir stratum with higher porosity and permeability and faster oil-water interface moving speed in the initial stage of water flooding is called a hypertonic zone.
Because the local permeability in the high-permeability zone reservoir is high, the water absorption capacity of a water injection well is high, the oil production in the initial stage of an oil production well is high, and a dominant seepage channel is easily formed after water injection, so that the water content of the reservoir rapidly rises, the high-permeability zone is seriously flooded with water, and finally the low oil reservoir extraction degree and the crude oil recovery ratio of the high-permeability zone are caused.
At present, in order to improve the oil reservoir recovery ratio of an oil reservoir stratum hypertonic zone, the following identification modes of the hypertonic zone can be mainly adopted:
(1) hypertonic zone identification mode based on interwell tracer technology
The method comprises the steps of inverting the logging response characteristics of a single layer of a reservoir through fitting an interwell tracer curve of the reservoir, predicting parameters such as permeability of the reservoir from the response characteristics of each layer, and determining whether a high permeable layer of the reservoir exists and the development condition according to the parameters.
However, the use of a hypertonic zone identification based on the interwell tracer technique requires a relatively long identification period.
(2) High-permeability zone identification method based on oil reservoir dynamic data
The method is characterized in that injection and production dynamics of an oil-water well are qualitatively analyzed through the lifting of an injection and production water volume curve, and the approximate distribution direction of a hypertonic zone is roughly judged according to the injection and production dynamic analysis result. The dynamic observation method can also be adopted, the water injection well is injected with water after stopping injection, and the approximate distribution direction of the high-permeability zone is determined by observing the change of the liquid production amount of the oil well. And an inter-well pressure pulse method can be adopted, the direction of the fastest water injection propulsion is determined according to the direction of the fastest pressure wave propagation, and the approximate distribution direction of the hypertonic zone is qualitatively judged according to the direction.
However, the identification method of the high permeability zone based on the dynamic data of the oil reservoir can only qualitatively determine the approximate distribution direction of the high permeability zone, and cannot quantitatively characterize the distribution condition of the high permeability zone.
(3) Hypertonic zone identification method based on logging data
However, when the hypertonic zone identification method based on the well-logging data is adopted, the distribution of the hypertonic zone can only be roughly expressed by taking the permeability in which range as the hypertonic zone, and the distribution of the hypertonic zone cannot be quantitatively determined.
An effective solution is not provided at present for how to rapidly and quantitatively determine the distribution situation of the hypertonic zone.
Disclosure of Invention
The invention provides a method and a device for determining a permeability lower limit value of a high permeability zone, which are used for achieving the purpose of quantitatively determining the distribution condition of the high permeability zone in a work area to be detected.
The embodiment of the invention provides a method for determining a permeability lower limit value of a hypertonic zone, which comprises the following steps: dividing a reservoir to be tested into a plurality of strata with the depth of a preset hypertonic zone thickness; setting a plurality of plunging coefficients, and determining the permeability of each stratum of the reservoir to be detected under each plunging coefficient according to the stratum parameters of the reservoir to be detected, wherein the stratum parameters comprise: average permeability; establishing an oil reservoir model of the reservoir to be tested for each plunging coefficient in the plurality of plunging coefficients according to the stratum parameters of the reservoir to be tested and the permeability of each stratum of the reservoir to be tested under each plunging coefficient; simulating oil extraction by using each oil reservoir model to obtain the oil reservoir extraction degree corresponding to each oil reservoir model; selecting inflection points of the oil reservoir extraction degree in the change relation, which is reduced along with the inrush coefficient within the range of a preset threshold value, based on the determined change relation of the oil reservoir extraction degree corresponding to each oil reservoir model along with the inrush coefficient, and taking the inrush coefficient corresponding to the inflection points as the reservoir inrush coefficient of the reservoir to be detected; and calculating to obtain the lower limit value of the permeability of the high permeability zone in the reservoir to be detected according to the reservoir plunging coefficient and the average permeability.
In one embodiment, the lower permeability limit of the high permeability zone in the reservoir to be tested may be calculated according to the reservoir breakthrough coefficient and the average permeability according to the following formula:
wherein, KminRepresenting the lower limit value of permeability of a high permeability zone in the reservoir to be detected, a is more than 0, TKRepresenting the reservoir kick-in coefficient,
the average permeability is expressed.
In one embodiment, the formation parameters may also include, but are not limited to, at least one of: average thickness of the formation, average porosity, and average saturation.
In an embodiment, based on a determined variation relationship between the oil reservoir extraction degree corresponding to each oil reservoir model and the breakthrough coefficient, selecting an inflection point in the variation relationship, where the oil reservoir extraction degree decreases with the breakthrough coefficient within a preset threshold range, and using the breakthrough coefficient corresponding to the inflection point as the reservoir breakthrough coefficient of the reservoir to be detected may include: selecting inflection points of which the oil reservoir extraction degree is reduced along with the inrush coefficient within a preset threshold range in the change relation of the oil reservoir extraction degree corresponding to each oil reservoir model along with the inrush coefficient to obtain a plurality of inflection points; obtaining the corresponding inrush coefficient of each inflection point in the plurality of inflection points to obtain a plurality of first inrush coefficients; and taking the average value of the first plunging coefficients as the reservoir plunging coefficient of the reservoir to be detected.
In one embodiment, determining the permeability of each stratum of the reservoir to be tested at each plunging coefficient according to the stratum parameters of the reservoir to be tested may include: setting the permeability of each stratum of the reservoir to be detected under the current plunging coefficient according to the following modes: setting an initial permeability value according to the average permeability; and setting the permeability of each stratum in the multiple stratums of the reservoir to be detected on the basis of the initial permeability value on the premise of ensuring that the ratio of the maximum permeability of each stratum to the average permeability is equal to the current plunging coefficient.
In one embodiment, before simulating oil production by using each reservoir model to obtain the corresponding reservoir production degree of each reservoir model, the method may further include: and water-driving each oil reservoir model until the water content reaches 98%.
In one embodiment, selecting an inflection point in the change relationship where the oil reservoir production degree decreases with the inrush coefficient within a preset threshold range based on the determined change relationship between the oil reservoir production degree corresponding to each oil reservoir model and the inrush coefficient may include: obtaining an expression which reflects the change relationship between the oil deposit extraction degree and the plunging coefficient corresponding to each oil deposit model according to the oil deposit extraction degree and the plunging coefficient corresponding to each oil deposit model; respectively finding out a first derivative and a second derivative of the expression relative to the plunging coefficient; and taking the point when the first derivative is constant and the second derivative is zero as an inflection point when the oil reservoir extraction degree is reduced along with the plunging coefficient within the range of a preset threshold value in the change relation.
The embodiment of the invention also provides a device for determining the permeability lower limit value of the hypertonic zone, which comprises the following steps: the stratum dividing module can be used for dividing the reservoir to be detected into a plurality of strata with the depth of a preset high permeability zone thickness; the permeability determining module may be configured to set a plurality of breakthrough coefficients, and determine, according to a formation parameter of the reservoir to be tested, a permeability of each formation of the reservoir to be tested under each breakthrough coefficient, where the formation parameter includes: average permeability; the reservoir model establishing module can be used for establishing a reservoir model of the reservoir to be detected for each breakthrough coefficient in the plurality of breakthrough coefficients according to the stratum parameters of the reservoir to be detected and the permeability of each stratum of the reservoir to be detected under each breakthrough coefficient; the oil reservoir recovery degree determining module can be used for simulating oil production by utilizing each oil reservoir model to obtain the oil reservoir recovery degree corresponding to each oil reservoir model; the outburst coefficient determining module is used for selecting inflection points of the oil reservoir extraction degree in the change relation, which is reduced along with the outburst coefficient within the range of a preset threshold value, based on the change relation of the oil reservoir extraction degree corresponding to each determined oil reservoir model along with the outburst coefficient, and taking the outburst coefficient corresponding to the inflection points as the reservoir outburst coefficient of the reservoir to be detected; and the lower limit value calculating module can be used for calculating and obtaining the lower limit value of the permeability of the high permeability zone in the reservoir to be detected according to the reservoir plunging coefficient and the average permeability.
In an embodiment, the lower limit value calculation module may be specifically configured to calculate a lower limit value of permeability of a high permeability zone in the reservoir to be tested according to the reservoir breakthrough coefficient and the average permeability according to the following formula:
wherein, KminRepresenting the lower limit value of permeability of a high permeability zone in the reservoir to be detected, a is more than 0, TKRepresenting the reservoir kick-in coefficient,
the average permeability is expressed.
In one embodiment, the formation parameters may also include, but are not limited to, at least one of: average thickness of the formation, average porosity, and average saturation.
In the embodiment of the invention, the reservoir model established for each plunging coefficient by the reservoir to be tested is used for simulating oil extraction, so that the reservoir extraction degrees corresponding to a plurality of plunging coefficients are obtained. And determining the reservoir inrush coefficient of the reservoir to be detected according to the determined variation relation of the oil reservoir extraction degree along with the inrush coefficient. And finally, calculating to obtain a permeability lower limit value of a high permeability zone in the reservoir to be tested according to the reservoir plunging coefficient and the average permeability, and developing petroleum. Aiming at the problems that the distribution condition of a high permeability zone cannot be quantitatively represented, the operation period is long and the cost is high in the prior art, the method provides that the lower limit value of the permeability of the high permeability zone in the reservoir to be detected is calculated and obtained by combining the average permeability under the condition that the reservoir plunging coefficient of the reservoir to be detected is obtained, so that the purpose of quantitatively determining the range of the high permeability zone of the reservoir to be detected is achieved, the lower limit value of the permeability obtained in the mode is more accurate, and the oil-gas exploration is guided by the determined accurate lower limit value of the permeability, so that the oil-gas exploitation efficiency can be effectively improved.
Drawings
In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without any creative effort.
FIG. 1 is a flow chart of a method for determining a lower permeability limit of a hypertonic zone provided herein;
FIG. 2 is a schematic diagram of the variation of the extraction degree with the plunging coefficient provided by the present application;
fig. 3 is a block diagram of a device for determining a permeability lower limit value of a hypertonic section.
Detailed Description
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present application.
Considering that the distribution of the hypertonic zones can only be roughly shown in the prior art, the specific distribution of the hypertonic zones cannot be accurately determined. The inventors contemplate that the distribution of the hypertonic zones can be determined quantitatively by accurately determining the lower limit of permeability of the hypertonic zones. In one embodiment, the method for determining the permeability lower limit value of the high-permeability zone in the reservoir to be tested can be realized by setting a plurality of plunging coefficients for the reservoir to be tested, establishing an oil reservoir model of the reservoir to be tested for each plunging coefficient in the plurality of plunging coefficients, and determining the plunging coefficients of the reservoir according to the variation relation of the oil reservoir extraction degree obtained by the oil reservoir model in the simulated oil recovery process along with the plunging coefficients. Based on this, a method for determining the permeability lower limit of the hypertonic zone is proposed, as shown in fig. 1, which may include the following steps:
s101: and dividing the reservoir to be tested into a plurality of strata with the depth of a preset hypertonic zone thickness.
In one embodiment of the present application, the reservoir to be tested may be a carbonate reservoir.
When the reservoir to be detected is divided, the total thickness of the reservoir to be detected is not changed, and the preset thickness of the high-permeability zone is changed. For example: the stratum thickness of the reservoir to be tested is 40m, and when the thickness of the preset high-permeability zone is 1m, the reservoir to be tested can be divided into 40 stratums with the depth equal to 1 m; when the preset thickness of the high-permeability zone is 2m, the reservoir to be measured can be divided into 20 stratums with the depth equal to 2 m. It should be noted, however, that the formation thickness and the predetermined hypertonic zone thickness listed above are only illustrative and that other values may be used when implemented, and the present application is not limited thereto.
S102: setting a plurality of plunging coefficients, and determining the permeability of each stratum of the reservoir to be detected under each plunging coefficient according to the stratum parameters of the reservoir to be detected, wherein the stratum parameters comprise: average permeability.
The formation parameters may include, but are not limited to, at least one of: average thickness of the formation, average permeability, average porosity and saturation, core porosity, permeability, facies permeability curve, mercury intrusion curve, fluid density, fluid viscosity, daily injection and daily production.
In an embodiment of the present application, after setting a plurality of breakthrough coefficients, the permeability of each stratum of the reservoir to be tested under the current breakthrough coefficient may be set as follows: setting an initial permeability value according to the average permeability; and based on the initial permeability value, on the premise of ensuring that the ratio of the maximum value of the permeability of each stratum to the average permeability is equal to the current plunging coefficient, the permeability of each stratum in the multiple strata of the reservoir to be detected.
The method for determining the permeability of each formation of the reservoir to be tested under the condition of setting the plunging coefficient is specifically described below with reference to a specific embodiment, however, it should be noted that the specific embodiment is only for better illustrating the present invention, and is not to be construed as a limitation to the present invention.
An oil field is a typical pore type biological debris limestone reservoir, the thickness of a stratum is 20m, the average porosity is 19.3%, the average permeability is 38mD, cracks do not develop, an internal development interlayer and a high permeability zone are formed, and the reservoir is strong in heterogeneity.
Setting the thickness of the preset hypertonic zone to be 0.5m, and obtaining 40 oil fields with the depth of 0.5m according to the thickness of the ground layer to be 20 m. The initial value of the permeability is set to be 20mD according to the average permeability of 38mD of a certain oil field. Then, based on the initial value of permeability of 20mD, the permeability of each of the multiple strata in a certain oilfield is shown in table 1 on the premise of ensuring that the ratio of the maximum value of the permeability of each stratum to the average permeability is equal to the current plunging coefficient:
TABLE 1 Permeability of each stratum of a certain field at each breakthrough factor at a zone thickness of 0.5m
Changing the thickness of a preset high-permeability zone, keeping the thickness of the stratum to be 20m, determining that the thicknesses of the high-permeability zones are respectively 1m, 2m, 3m, 4m, 5m, 7m, 10m, 13m, 16m and 20m, and the penetration coefficients are respectively 2.0, 3.0, 4.0, 6.0, 8.0, 10.0, 15.0, 20.0, 25.0 and 50.0, and totally 300 conditions of the permeability of each stratum in a certain area.
S103: and establishing an oil reservoir model of the reservoir to be tested for each plunging coefficient in the plurality of plunging coefficients according to the stratum parameters of the reservoir to be tested and the permeability of each stratum of the reservoir to be tested under each plunging coefficient.
And under the condition that the permeability of each stratum of the reservoir to be detected under each plunging coefficient is obtained, establishing an oil reservoir model of the reservoir to be detected for each plunging coefficient in the plurality of plunging coefficients by combining the stratum parameters of the reservoir to be detected.
For example, the permeability of 300 cases obtained from the area and the formation parameter measured from the area itself are respectively: and determining the oil reservoir model under each condition according to parameters such as average permeability, average porosity and saturation, core porosity and the like, and obtaining 300 oil reservoir models in total.
S104: and simulating oil extraction by using each oil reservoir model to obtain the oil reservoir extraction degree corresponding to each oil reservoir model.
Under the condition of the obtained multiple groups of models, the injection and extraction capacity of the oil well is obtained from the existing data, the production allocation and injection allocation of the oil well and the water well in the oil reservoir model are controlled within the range of the value, and the injection and extraction balance in the development process is realized to keep the pressure level. And (4) under the condition that the water content of each oil reservoir model is driven by water to reach 98%, simulating to obtain the oil reservoir extraction degree under different conditions.
For the certain area, the injection and production capacity of the oil well is obtained according to the existing data. And under the condition that the water content of each oil reservoir model is driven by water to reach 98%, simulating to obtain the oil reservoir extraction degree corresponding to the oil reservoir model under different conditions.
S105: and selecting inflection points of which the oil reservoir extraction degree is reduced along with the inrush coefficient within a preset threshold range in the change relation based on the determined change relation of the oil reservoir extraction degree corresponding to each oil reservoir model along with the inrush coefficient, and taking the inrush coefficient corresponding to the inflection points as the reservoir inrush coefficient of the reservoir to be detected.
The reservoir kick-in coefficient of the reservoir to be tested can be determined in the following manner:
s5-1: and obtaining an expression reflecting the change relation between the oil deposit extraction degree and the plunging coefficient corresponding to each oil deposit model according to the oil deposit extraction degree and the plunging coefficient corresponding to each oil deposit model.
S5-2: and respectively calculating the first derivative and the second derivative of the expression relative to the plunging coefficient.
S5-3: and taking the point when the first derivative is constant and the second derivative is zero as an inflection point of the change relation, wherein the oil reservoir extraction degree is reduced along with the plunging coefficient within the preset threshold range.
Further, after obtaining an inflection point, namely a reservoir breakthrough coefficient, determined by a change relation of the reservoir extraction degree of a reservoir model established by a stratum with a preset hyperosmotic zone thickness (0.5m) under each breakthrough coefficient along with the change relation of the breakthrough coefficient, other preset hyperosmotic zone thicknesses may be selected, for example: 1m, 2m, 3m, 4m, 5m, 7m, 10m, 13m, 16m and 20m, determining reservoir inrush coefficients which are inflection points determined by the variation relation of the reservoir extraction degree of the reservoir model established by the stratums with the high permeability zone thickness under each inrush coefficient along with the inrush coefficient, and obtaining a plurality of first inrush coefficients by obtaining the inrush coefficients corresponding to the inflection points in the inflection points; and taking the average value of the first plunging coefficients as the reservoir plunging coefficient of the reservoir to be detected.
According to the change relationship between the extraction degree of the oil reservoir and the plunging coefficient obtained in a certain area, a graph of the change relationship between the extraction degree and the plunging coefficient can be obtained by plotting, and is shown in fig. 2. In FIG. 2, the thickness of the hypertonic zone is increased from 1m to 20m, and the crude oil production degree is correspondingly changed along with the change of the thickness of the hypertonic zone. As can be seen from fig. 2: when the thickness of the high-permeability zone is constant, the permeability breakthrough coefficient is increased, and the crude oil extraction degree is reduced; the stratum with the same outburst coefficient and different high permeability layer thicknesses has the advantages that when the thickness of the high permeability layer is increased and is smaller than 10m, the extraction degree of crude oil is reduced along with the increase of the thickness of a high permeability zone, and when the thickness of the high permeability layer is larger than 10m, the extraction degree of crude oil is increased along with the increase of the thickness of the high permeability layer; no matter how thick the hypertonic layer is, the crude oil production degree is rapidly reduced when the permeability breakthrough coefficient is 5 to 10. Therefore, the first plunging coefficients at the inflection points of the different hypertonic zone thicknesses are counted as shown in table 2, and the average value of the first plunging coefficients at the plurality of hypertonic zone thicknesses is 5.3, that is, 5.3 can be used as the reservoir plunging coefficient of a certain oil field.
TABLE 2 first plunging coefficient at lower inflection points for different hypertonic zones
S106: and calculating to obtain the permeability lower limit value of the high permeability zone in the reservoir to be detected according to the reservoir plunging coefficient and the average permeability.
Specifically, the permeability lower limit value of the high permeability zone in the reservoir to be measured can be calculated according to the reservoir breakthrough coefficient and the average permeability according to the following formula:
wherein, KminRepresenting the lower limit value of permeability of a high permeability zone in the reservoir to be detected, a is more than 0, TKThe coefficient of the reservoir breakthrough is represented,
mean permeability is indicated.
In the above embodiment, when a is 1, the value may be determined according to a certain oilfield reservoir breakthrough coefficient of 5.3 and an average permeability value of 38mD obtained from core data test
Can countThe lower limit of the permeability of the oilfield hyperosmotic zone was calculated to be 201.4 mD.
In one embodiment of the application, the water absorption capacity of the water injection well is high due to high local permeability in the reservoir of the hypertonic zone, the oil production of the oil production well at the initial stage is high, and a dominant seepage channel is easily formed after water injection, so that the water content of the reservoir rises rapidly, the hypertonic zone is seriously flooded with water, and finally the low oil reservoir extraction degree and the crude oil recovery rate of the hypertonic zone are caused. Therefore, the distribution condition of the high-permeability zone in the reservoir to be tested can be determined according to the lower limit value of the high-permeability zone permeability obtained by the method of the steps S101 to S106, and oil exploration is carried out according to the lower limit value of the high-permeability zone permeability, so that a foundation is provided for later-period oilfield flooding and flooding development dynamic prediction.
Based on the same inventive concept, the embodiment of the present invention further provides a device for determining the permeability lower limit value of the hypertonic section, as described in the following embodiments. Because the principle of solving the problem of the determination device for the permeability lower limit value of the hypertonic zone is similar to the determination method for the permeability lower limit value of the hypertonic zone, the implementation of the determination device for the permeability lower limit value of the hypertonic zone can refer to the implementation of the determination method for the permeability lower limit value of the hypertonic zone, and repeated details are omitted. As used hereinafter, the term "unit" or "module" may be a combination of software and/or hardware that implements a predetermined function. Although the means described in the embodiments below are preferably implemented in software, an implementation in hardware, or a combination of software and hardware is also possible and contemplated. Fig. 3 is a block diagram of a configuration of an apparatus for determining a lower permeability limit of a hypertonic zone according to an embodiment of the present invention, as shown in fig. 3, which may include: the system comprises a stratum dividing module 301, a permeability determining module 302, a reservoir model establishing module 303, a mining degree determining module 304, a plunging coefficient determining module 305 and a lower limit value calculating module 306, and the structure is explained below.
The stratum dividing module 301 may be configured to divide the reservoir to be tested into a plurality of strata with a depth equal to a preset hypertonic zone thickness;
the permeability determining module 302 may be configured to set a plurality of breakthrough coefficients, and determine, according to a formation parameter of the reservoir to be tested, a permeability of each formation of the reservoir to be tested under each breakthrough coefficient, where the formation parameter includes: average permeability;
the reservoir model establishing module 303 may be configured to establish a reservoir model of the reservoir to be tested for each breakthrough coefficient in the plurality of breakthrough coefficients according to the formation parameter of the reservoir to be tested and the permeability of each formation of the reservoir to be tested under each breakthrough coefficient;
the recovery degree determining module 304 may be configured to utilize each oil reservoir model to simulate oil recovery, so as to obtain an oil reservoir recovery degree corresponding to each oil reservoir model;
the inrush coefficient determining module 305 may be configured to select an inflection point in the change relationship, where the oil reservoir extraction degree decreases with an inrush coefficient within a preset threshold range, based on the change relationship between the determined oil reservoir extraction degree corresponding to each oil reservoir model and the inrush coefficient, and use the inrush coefficient corresponding to the inflection point as the reservoir inrush coefficient of the reservoir to be detected;
the lower limit value calculating module 306 may be configured to calculate a lower limit value of the permeability of the high permeability zone in the reservoir to be detected according to the reservoir breakthrough coefficient and the average permeability.
In an embodiment, the lower limit value calculation module may be specifically configured to calculate a lower limit value of permeability of a high permeability zone in the reservoir to be tested according to the reservoir breakthrough coefficient and the average permeability according to the following formula:
wherein, KminRepresenting the lower limit value of permeability of a high permeability zone in the reservoir to be detected, a is more than 0, TKRepresenting the reservoir kick-in coefficient,
the average permeability is expressed.
In one embodiment, the formation parameters may also include, but are not limited to, at least one of: average thickness of the formation, average porosity, and average saturation.
In one embodiment, the plunging coefficient determination module may include: the inflection point selecting unit can be used for selecting inflection points of which the oil reservoir extraction degree decreases along with the inrush coefficient within the range of a preset threshold value in the change relation of the oil reservoir extraction degree corresponding to each oil reservoir model along with the inrush coefficient to obtain a plurality of inflection points; an abrupt coefficient obtaining unit, configured to obtain an abrupt coefficient corresponding to each inflection point of the multiple inflection points, and obtain multiple first abrupt coefficients; and the reservoir breakthrough coefficient unit can be used for taking the average value of the first breakthrough coefficients as the reservoir breakthrough coefficient of the reservoir to be detected.
In one embodiment, the permeability determination module may set the permeability of each stratum of the reservoir to be tested at the current breakthrough coefficient in the following manner: setting an initial permeability value according to the average permeability; and setting the permeability of each stratum in the multiple stratums of the reservoir to be detected on the basis of the initial permeability value on the premise of ensuring that the ratio of the maximum permeability of each stratum to the average permeability is equal to the current plunging coefficient.
In an embodiment, before the module for determining the recovery degree simulates oil recovery by using each reservoir model to obtain the reservoir recovery degree corresponding to each reservoir model, the module for determining the recovery degree may further include: and water-driving each oil reservoir model until the water content reaches 98%.
In one embodiment, the plunging coefficient determination module may include: the expression determining unit can be used for obtaining an expression reflecting the change relationship between the oil deposit extraction degree and the penetration coefficient corresponding to each oil deposit model according to the oil deposit extraction degree and the penetration coefficient corresponding to each oil deposit model; a derivative calculating unit, configured to calculate a first derivative and a second derivative of the expression with respect to the inrush coefficient, respectively; the inrush inflection point determining unit may be configured to use a point at which the first derivative is a constant and the second derivative is zero as an inflection point at which the oil reservoir extraction degree decreases with the inrush coefficient within a preset threshold range in the variation relation.
From the above description, it can be seen that the embodiments of the present invention achieve the following technical effects: and simulating oil extraction by using an oil reservoir model established for each plunging coefficient by using the reservoir to be detected to obtain the oil reservoir extraction degree corresponding to the plunging coefficients. And determining the reservoir inrush coefficient of the reservoir to be detected according to the determined variation relation of the oil reservoir extraction degree along with the inrush coefficient. And finally, calculating to obtain a permeability lower limit value of a high permeability zone in the reservoir to be detected according to the reservoir plunging coefficient and the average permeability, and carrying out oil exploration. Aiming at the problems that the distribution condition of a hypertonic zone cannot be quantitatively represented, the operation period is long and the cost is high in the prior art, the method provides that the lower limit value of the permeability of the hypertonic zone in the reservoir to be detected is calculated by combining the average permeability under the condition that the reservoir plunging coefficient of the reservoir to be detected is obtained, so that the purpose of quantitatively determining the range of the hypertonic zone of the reservoir to be detected is achieved. The method is simple to operate, can provide a basis for prediction of the high permeability zone, and has important significance for guiding water injection of the oil production well in the later period.
Although the description of establishing a reservoir model of a reservoir to be tested, simulating oil production by using the reservoir model, obtaining inflection points in a change relationship, etc. is mentioned in the present disclosure, the present disclosure is not limited to the case described in the embodiments of the present disclosure. Certain industry standards, or implementations modified slightly from those described using custom modes or examples, may also achieve the same, equivalent, or similar, or other, contemplated implementations of the above-described examples. The embodiments of establishing the reservoir model of the reservoir to be measured, simulating oil production by using the reservoir model, obtaining inflection points in the change relationship and the like, which are obtained after the modification or deformation, are applied, and still can belong to the scope of the optional embodiments of the present application.
Although the present application provides method steps as described in an embodiment or flowchart, more or fewer steps may be included based on conventional or non-inventive means. The order of steps recited in the embodiments is merely one manner of performing the steps in a multitude of orders and does not represent the only order of execution. When an actual apparatus or end product executes, it may execute sequentially or in parallel (e.g., parallel processors or multi-threaded environments, or even distributed data processing environments) according to the method shown in the embodiment or the figures. The terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, the presence of additional identical or equivalent elements in a process, method, article, or apparatus that comprises the recited elements is not excluded.
The units, devices, modules, etc. set forth in the above embodiments may be implemented by a computer chip or an entity, or by a product with certain functions. For convenience of description, the above devices are described as being divided into various modules by functions, and are described separately. Of course, in implementing the present application, the functions of each module may be implemented in one or more software and/or hardware, or a module implementing the same function may be implemented by a combination of a plurality of sub-modules or sub-units, and the like. The above-described embodiments of the apparatus are merely illustrative, and for example, the division of the units is only one logical division, and other divisions may be realized in practice, for example, a plurality of units or components may be combined or integrated into another system, or some features may be omitted, or not executed. In addition, the shown or discussed mutual coupling or direct coupling or communication connection may be an indirect coupling or communication connection through some interfaces, devices or units, and may be in an electrical, mechanical or other form.
Those skilled in the art will also appreciate that, in addition to implementing the controller as pure computer readable program code, the same functionality can be implemented by logically programming method steps such that the controller is in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers and the like. Such a controller may therefore be considered as a hardware component, and the means included therein for performing the various functions may also be considered as a structure within the hardware component. Or even means for performing the functions may be regarded as being both a software module for performing the method and a structure within a hardware component.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, classes, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
From the above description of the embodiments, it is clear to those skilled in the art that the present application can be implemented by software plus necessary general hardware platform. Based on such understanding, the technical solutions of the present application may be embodied in the form of a software product, which may be stored in a storage medium, such as a ROM/RAM, a magnetic disk, an optical disk, or the like, and includes several instructions for enabling a computer device (which may be a personal computer, a mobile terminal, a server, or a network device) to execute the method according to the embodiments or some parts of the embodiments of the present application.
The embodiments in the present specification are described in a progressive manner, and the same or similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. The application is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable electronic devices, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
While the present application has been described with examples, those of ordinary skill in the art will appreciate that there are numerous variations and permutations of the present application without departing from the spirit of the application, and it is intended that the appended claims encompass such variations and permutations without departing from the spirit of the application.
Claims (9)
1. A method for determining a permeability lower limit value of a hypertonic section, comprising:
dividing a reservoir to be tested into a plurality of strata with the depth of a preset hypertonic zone thickness;
setting a plurality of plunging coefficients, and determining the permeability of each stratum of the reservoir to be detected under each plunging coefficient according to the stratum parameters of the reservoir to be detected, wherein the stratum parameters comprise: average permeability;
establishing an oil reservoir model of the reservoir to be tested for each plunging coefficient in the plurality of plunging coefficients according to the stratum parameters of the reservoir to be tested and the permeability of each stratum of the reservoir to be tested under each plunging coefficient;
simulating oil extraction by using each oil reservoir model to obtain the oil reservoir extraction degree corresponding to each oil reservoir model;
based on the determined change relationship between the oil reservoir extraction degree corresponding to each oil reservoir model and the plunging coefficient, selecting an inflection point in the change relationship, wherein the oil reservoir extraction degree is reduced along with the plunging coefficient within a preset threshold range, and taking the plunging coefficient corresponding to the inflection point as the reservoir plunging coefficient of the reservoir to be detected, wherein the method comprises the following steps: selecting inflection points of which the oil reservoir extraction degree is reduced along with the inrush coefficient within a preset threshold range in the change relation of the oil reservoir extraction degree corresponding to each oil reservoir model along with the inrush coefficient to obtain a plurality of inflection points; obtaining the corresponding inrush coefficient of each inflection point in the plurality of inflection points to obtain a plurality of first inrush coefficients; taking the average value of the first plunging coefficients as the reservoir plunging coefficient of the reservoir to be detected;
and calculating to obtain the lower limit value of the permeability of the high permeability zone in the reservoir to be detected according to the reservoir plunging coefficient and the average permeability.
2. The method of claim 1, wherein the lower permeability limit of the high permeability zone in the reservoir to be tested is calculated according to the reservoir breakthrough coefficient and the average permeability according to the following formula:
wherein, KminRepresenting the lower limit value of permeability of a high permeability zone in the reservoir to be detected, a is more than 0, TKRepresenting the reservoir kick-in coefficient,
the average permeability is expressed.
3. The method of claim 1, wherein the formation parameters further comprise at least one of: average thickness of the formation, average porosity, and average saturation.
4. The method of claim 1, wherein determining the permeability of each formation of the reservoir under test at each plunging coefficient based on formation parameters of the reservoir under test comprises:
setting the permeability of each stratum of the reservoir to be detected under the current plunging coefficient according to the following modes:
setting an initial permeability value according to the average permeability;
and setting the permeability of each stratum in the multiple stratums of the reservoir to be detected on the basis of the initial permeability value on the premise of ensuring that the ratio of the maximum permeability of each stratum to the average permeability is equal to the current plunging coefficient.
5. The method of claim 1, wherein before simulating oil recovery using each reservoir model to obtain the extent of reservoir production corresponding to each reservoir model, the method further comprises:
and water-driving each oil reservoir model until the water content reaches 98%.
6. The method of claim 1, wherein selecting an inflection point in the change relation where the reservoir production degree decreases with the inrush coefficient within a preset threshold based on the determined change relation between the reservoir production degree corresponding to each reservoir model and the inrush coefficient comprises:
obtaining an expression which reflects the change relationship between the oil deposit extraction degree and the plunging coefficient corresponding to each oil deposit model according to the oil deposit extraction degree and the plunging coefficient corresponding to each oil deposit model;
respectively finding out a first derivative and a second derivative of the expression relative to the plunging coefficient;
and taking the point when the first derivative is constant and the second derivative is zero as an inflection point when the oil reservoir extraction degree is reduced along with the plunging coefficient within the range of a preset threshold value in the change relation.
7. An apparatus for determining a lower permeability limit of a hypertonic section, comprising:
the stratum dividing module is used for dividing the reservoir to be detected into a plurality of strata with the depth being the preset high permeability zone thickness;
and the permeability determining module is used for setting a plurality of plunging coefficients and determining the permeability of each stratum of the reservoir to be detected under each plunging coefficient according to the stratum parameters of the reservoir to be detected, wherein the stratum parameters comprise: average permeability;
the reservoir model establishing module is used for establishing a reservoir model of the reservoir to be tested for each inrush coefficient in the plurality of inrush coefficients according to the stratum parameters of the reservoir to be tested and the permeability of each stratum of the reservoir to be tested under each inrush coefficient;
the oil reservoir recovery degree determining module is used for simulating oil extraction by utilizing each oil reservoir model to obtain the oil reservoir recovery degree corresponding to each oil reservoir model;
the outburst coefficient determining module is used for selecting an inflection point of the oil reservoir extraction degree in the change relation, which is reduced along with the outburst coefficient within a preset threshold range, based on the change relation of the oil reservoir extraction degree corresponding to each determined oil reservoir model along with the outburst coefficient, and taking the outburst coefficient corresponding to the inflection point as the reservoir outburst coefficient of the reservoir to be detected, and comprises the following steps: selecting inflection points of which the oil reservoir extraction degree is reduced along with the inrush coefficient within a preset threshold range in the change relation of the oil reservoir extraction degree corresponding to each oil reservoir model along with the inrush coefficient to obtain a plurality of inflection points; obtaining the corresponding inrush coefficient of each inflection point in the plurality of inflection points to obtain a plurality of first inrush coefficients; taking the average value of the first plunging coefficients as the reservoir plunging coefficient of the reservoir to be detected;
and the lower limit value calculating module is used for calculating and obtaining the lower limit value of the permeability of the high permeability zone in the reservoir to be detected according to the reservoir plunging coefficient and the average permeability.
8. The apparatus according to claim 7, wherein the lower limit calculation module is specifically configured to calculate a lower limit of permeability of a high permeability zone in the reservoir to be tested according to the reservoir breakthrough coefficient and the average permeability according to the following formula:
wherein, KminRepresenting the lower limit value of permeability of a high permeability zone in the reservoir to be detected, a is more than 0, TKRepresenting the reservoir kick-in coefficient,
the average permeability is expressed.
9. The apparatus of claim 7, wherein the formation parameters further comprise at least one of: average thickness of the formation, average porosity, and average saturation.
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